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WO2020097489A1 - Fluides de puits de forage à rhéologie plate pour générer des puits de forage propres - Google Patents

Fluides de puits de forage à rhéologie plate pour générer des puits de forage propres Download PDF

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Publication number
WO2020097489A1
WO2020097489A1 PCT/US2019/060513 US2019060513W WO2020097489A1 WO 2020097489 A1 WO2020097489 A1 WO 2020097489A1 US 2019060513 W US2019060513 W US 2019060513W WO 2020097489 A1 WO2020097489 A1 WO 2020097489A1
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WO
WIPO (PCT)
Prior art keywords
wellbore
oleaginous
wellbore fluid
minute
drilling
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2019/060513
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English (en)
Inventor
Damian R. VICKERS
Chemsseddine BOUGUETTA
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MI LLC
Original Assignee
MI LLC
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Filing date
Publication date
Application filed by MI LLC filed Critical MI LLC
Priority to BR112021008937-3A priority Critical patent/BR112021008937A2/pt
Priority to US17/291,627 priority patent/US11624018B2/en
Publication of WO2020097489A1 publication Critical patent/WO2020097489A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C09K8/36—Water-in-oil emulsions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes

Definitions

  • various fluids may be used in the well for a variety of functions.
  • the fluids may be circulated through a bore hole, which may subsequently flow upward through the wellbore to the surface.
  • the drilling fluid may remove drill cuttings from the bottom of the hole to the surface, to suspend cuttings and weighting material when circulation is interrupted, to control subsurface pressures, to maintain the integrity of the wellbore until the well section is cased and cemented, to isolate the fluids from the formation by providing sufficient hydrostatic pressure to prevent the ingress of formation fluids into the wellbore, to cool and lubricate the drill string and bit, and/or to maximize penetration rate.
  • Wellbore fluids may take the form of oil-based fluids such as invert emulsion muds.
  • the components of the invert emulsion fluids include an oleaginous liquid such as hydrocarbon oil which serves as a continuous phase, a non-oleaginous liquid such as water or brine solution which serves as a discontinuous phase, and an emulsifying agent.
  • Emulsifying agents may be used to lower the interfacial tension of the liquids so that the non-oleaginous liquid may form a stable dispersion of fine droplets in the oleaginous liquid.
  • such invert emulsion fluids may contain one or more weighting agents, surfactants, viscosifiers, fluid loss control agents or bridging agents.
  • embodiments disclosed herein relate to flat rheology fluids that provide optimum properties for use during wellbore construction that produces clean wellbore holes and eliminates or minimizes conditioning needed for prior to cement and liner operations.
  • Wellbore fluids in accordance with the present disclosure include are flat rheology invert emulsion fluids containing an amidoamine emulsifier and a combination of wetting agents and/or rheology modifiers.
  • Drilling fluids for deepwater applications may be designed to maintain flat rheology for drill cuttings transport and weight material suspension.
  • Flat rheology is a concept centered around uniformity of rheological properties over ranges of temperatures, pressures, or shear rates.
  • Flat rheology fluids provide improved hole cleaning characteristics and minimize frictional pressure losses over conventional non flat deepwater drilling fluids.
  • Flat rheology systems often combine good cuttings transport, better weight material suspension, and reduced impact on annular pressure losses.
  • a successful cement job is defined as (1) casing or liner run to section TD without obstruction or excessive downhole losses, and (2) a cementation in place that provides full zonal isolation without remedial measures such as top squeezing.
  • Traditional flat rheology systems may be used to drill clean wellbores, but require excessive rig time to be conditioned prior to installation of casing or lining and may compromise the drilling rates to section TD in order to achieve a successful isolation of the overburden formations and provide a strong coal seam gas (CSG)/Liner shoe for the sections to be drilled ahead.
  • CSG coal seam gas
  • flat rheology wellbore fluids may be formulated to remove cutings and residues generated while drilling, producing a clean wellbore that does not alter the chemical nature or modify the performance of treatments injected subsequently.
  • flat rheology wellbore fluids may be applied to deepwater applications, which include the use of flat rheology fluids in drilling with enhanced penetration rates, and for preparation for cement jobs without excessive and costly dilution or lengthy conditioning times.
  • the fluids of the present disclosure may have a flat rheology across temperature fluctuations, it is believed that in reaching total depth, there is a change in the fluid at higher pressures. Specifically, as pressure increases with a deeper well, the fluid may thicken, thereby improving the carrying capacity of the fluid. Thus, the change in fluid properties at TD may allow for the fluid to beter carry the cuttings from the hole botom to the surface, and therefore reduce the amount of conditioning needed. Such reduction may be a reduction by least 25%, 50%, or 75% of the conventional conditioning time and/or volume. For example, it is envisioned that the well may be circulated for less than two hole volumes, less than 1.5 hole volumes, less than 1 hole volume, or less than 0.5 hole volume.
  • Flat rheology wellbore fluids in accordance with the present disclosure may include an invert emulsion having a continuous oleaginous phase and a discontinuous aqueous (or non-oleaginous liquid) phase, among other substances and additives.
  • Wellbore treatment fluids in accordance with the present disclosure may be formulated as a water-in-oil emulsion and, in some cases, a high internal phase ratio (HIPR) emulsion in which the volume fraction of the internal aqueous phase is a high as 90 to 95 percent.
  • HIPR high internal phase ratio
  • flat rheology wellbore fluids may include an invert emulsion having an oleaginous external phase and a non-oleaginous internal phase.
  • the invert emulsion may also include a blend of emulsifiers, such as an amidoamine primary emulsifier, and a blend of oil weting agents, rheology modifiers, weighting agents, temperature stabilizing agents, thinners, and other various additives.
  • emulsifiers such as an amidoamine primary emulsifier
  • “flat rheology” means that the wellbore fluid maintains consistent rheological properties over temperature ranges from 40° F to 250° F or even 300° F.
  • the rheological properties of general focus for a flat rheology profile include 6 rpm, 10 minute gel (10'), Yield Point (YP), and 10 minute-to-lO second gel ratio (10': 10" gel ratio).
  • 6 rpm, 10' gel, and YP a system is considered to have a flat rheology profile when these values are within +/ 20% of the mean values across temperature ranges from 40° F to 300° F.
  • Flat rheology wellbore fluids in accordance with the present disclosure include an oleaginous external phase and a non-oleaginous (aqueous) internal phase.
  • Suitable oleaginous fluids that may be used to formulate invert emulsions may include a natural or synthetic oils such as diesel oil, mineral oil, synthetic oils such as such as hydrogenated and unhydrogenated olefins, polyalpha olefins, linear and branch olefins, and the like, polydiorganosiloxanes, siloxanes, or organosiloxanes, esters of fatty acids such as straight chain, branched and cyclical alkyl ethers of fatty acids; and mixtures thereof.
  • natural or synthetic oils such as diesel oil, mineral oil, synthetic oils such as such as hydrogenated and unhydrogenated olefins, polyalpha olefins, linear and branch olefins, and the like, polydiorganosiloxanes
  • wellbore fluids may include an oleaginous continuous phase that includes one or more Cl 6 to Cl 8 olefins.
  • the oleaginous continuous phase may include one or more internal olefins.
  • invert emulsions may include an oleaginous external phase a percent by volume (vol%) of the wellbore fluid in a range having a lower limit selected from any one of 30 vol%, 40 vol%, 50 vol%, and 60 vol%, to an upper limit selected from any one of 70 vol%, 80 vol%, 95 vol%, and 99 vol%, where any lower limit may be combined with any upper limit.
  • the amount of oleaginous liquid in the invert emulsion fluid may vary depending upon the particular oleaginous fluid used and the particular application in which the invert emulsion fluid is to be employed.
  • Invert emulsions in accordance with the present disclosure include a non- oleaginous (aqueous) internal phase.
  • Non-oleaginous liquids may include at least one of fresh water, sea water, brine, mixtures of water and water-soluble organic compounds, and mixtures thereof.
  • the non-oleaginous fluid may be a brine, which may include seawater, aqueous solutions wherein the salt concentration is less than that of sea water, or aqueous solutions wherein the salt concentration is greater than that of sea water.
  • non-oleaginous fluids may include brines prepared from organic salts, such as sodium, potassium, or cesium formate, and/or inorganic salts such as halides selected from the group of alkaline earth halides or zinc halides, including calcium chloride or calcium bromide.
  • halides selected from the group of alkaline earth halides or zinc halides, including calcium chloride or calcium bromide.
  • Sodium bromide, potassium bromide, or cesium bromide or other monovalent halides may also be used.
  • the salt may be chosen for compatibility reasons, such as when where the reservoir drilling fluid used a particular brine phase and the completion/clean up fluid brine phase is chosen to have the same brine phase.
  • invert emulsions may include a non-oleaginous internal phase a percent by volume (vol%) of the wellbore fluid in a range having a lower limit selected from any one of 1 vol%, 5 vol%, 10 vol%, 25 vol%, 50 vol%, and 60 vol%, to an upper limit selected from any one of 25 vol%, 30 vol%, 50 vol%, 60 vol%, and 70 vol%, where any lower limit may be combined with any upper limit.
  • the non-oleaginous internal phase may include calcium chloride present at a percent by volume (vol%) of the wellbore fluid in the range of 5 vol% to 30 vol%.
  • Emulsifier Flat rheology wellbore fluids in accordance with the present disclosure may include a primary emulsifier based on amidoamine chemistry in some embodiments.
  • Amidoamines that provide fluids with flat rheology profiles may include amidoamines formed from reacting one or more fatty reagents with a polyamine.
  • Polyamines that may be used to prepare amidoamines in accordance with the present disclosure may include linear or branched organophilic C6-C36 fatty polyamines including polyaliphatic polyamines, heterocyclic polyamines, and the like.
  • polyamines may include polyethylene polyamines such as diethylene triamine, triethylene tetramine, and tetraethylene pentamine.
  • Fatty reagents in accordance with the present disclosure may include saturated and unsaturated, branched and linear, fatty acids, including C6-C30 fatty acids such as lauric acid, myristic acid, palmitic acid, stearic acid, oleic acid, linoleic acid, tall oil or fatty acids (TOFA); C6-C30 alkenyl acids, C6-C30 arylalkyl acids, C6-C30 cycloalkyl acid.
  • Exemplary emulsifiers in accordance with the present disclosure may include RheMulTM and SUREMULTM, which are commercially available emulsifiers manufactured and distributed by M-I, L.L.C.
  • Fatty acid oil wetting agents in accordance with the present disclosure may include saturated and unsaturated, branched and linear, fatty acids, including C6-C30 fatty acids such as lauric acid, myristic acid, palmitic acid, stearic acid, oleic acid, linoleic acid, tall oil or fatty acids (TOFA); C6-C30 alkenyl acids, C6-C30 arylalkyl acids, C6-C30 cycloalkyl acid.
  • C6-C30 fatty acids such as lauric acid, myristic acid, palmitic acid, stearic acid, oleic acid, linoleic acid, tall oil or fatty acids (TOFA); C6-C30 alkenyl acids, C6-C30 arylalkyl acids, C6-C30 cycloalkyl acid.
  • R may be a C10-28 alkyl group (either linear or branched, saturated or unsaturated) and n may range between 2 and 6 (or 3 and 5 in some embodiments). Further, it is also envisioned that R and n are not limited to such ranges, but may be selected such that the resulting HLB is within the ranges described herein. In particular embodiments, R may be an oleyl group, a stearyl group, a tridecyl group, or a lauryl group.
  • the wetting agent may be at least one alcohol ethoxylate selected from group of oleyl alcohol-2- ethyoxylate, oleyl alcohol-3-ethyoxylate, oleyl alcohol-5-ethyoxylate, stearyl alcohol-2- ethyoxylate, stearyl alcohol-3-ethyoxylate, lauryl alcohol-4-ethyoxylate, and tridecyl alcohol-3-ethyoxylate.
  • alcohol ethoxylate selected from group of oleyl alcohol-2- ethyoxylate, oleyl alcohol-3-ethyoxylate, oleyl alcohol-5-ethyoxylate, stearyl alcohol-2- ethyoxylate, stearyl alcohol-3-ethyoxylate, lauryl alcohol-4-ethyoxylate, and tridecyl alcohol-3-ethyoxylate.
  • the fatty alcohol ethoxylate of the present disclosure may be depicted by Formula II below.
  • Formula II represents a secondary alcohol ethoxylate.
  • the secondary alcohol ethoxylate of Formula II has an n2 value of 2.
  • Examples of fatty alcohol alkoxylates also include octyl alcohol ethoxylate, caprylic alcohol ethoxylate, decyl alcohol ethoxylate, lauryl alcohol, oleyl alcohol ethoxylate, oleyl alcohol-3 ethoxylate, palmitoleic alcohol ethoxylate, isostearyl alcohol ethoxylate, octyl dodecanol ethoxylate, octyl decanol ethoxylate, equivalent propylated and iso-propylated derivatives, and the like.
  • FAZEWETTM, RHECONTM, VERSACOATTM, SUREWETTM, VERSAWETTM, RHECONTM, MEGAMULTM, SUREMULTM, ONEMULTM, ACTIMUL RDTM, MUL-XTTM, and VERSAWETTM NS are examples of commercially available wetting agents manufactured and distributed by M-I L.L.C. that may be used in the fluids disclosed herein.
  • Flat rheology wellbore fluids in accordance with the present disclosure may include one or more rheology modifiers that modify low shear rate viscosity (LSRV) for the fluid system.
  • rheology modifiers may reduce the increase in viscosity (flatten the rheological characteristics) of the wellbore fluid over a temperature range from about 40° F to about 150° F.
  • Rheology modifiers in accordance with the present disclosure may be one or more poly-carboxylic fatty acids generated from the polymerization/oligomerization of unsaturated fatty acids.
  • Poly-carboxylic fatty acids may include dimer poly-carboxylic C12 to C22 fatty acids, trimer poly-carboxylic C12 to C22 fatty acids, tetramer poly- carboxylic C12 to C22 fatty acid, and mixtures of such acids.
  • rheology modifiers may be prepared by dimerization/trimerization of unsaturated fatty acids containing from 8 to about 18 carbon atoms, including 9-dodecenoic(cis), 9- tetradecenoic(cis), 9-octadecenoic(cis), octadecatetranoic acids, and the like.
  • Rheology modifiers in accordance with the present disclosure may include SUREMODTM and RHEFLATTM, which are commercially available rheology modifiers manufactured and distributed by M-I L.L.C. that may be used in the fluids disclosed herein.
  • Flat rheology wellbore fluids in accordance with the present disclosure may include a number of additives that modify various properties of the fluids such as organophilic clays, viscosifiers, weighting agents, bridging agents, fluid loss control agents, additives to reduce or control low temperature rheology, additives to provide thinning, additives for enhancing viscosity, additives for high temperature high pressure control, emulsion stability, and inhibit corrosion.
  • additives that modify various properties of the fluids such as organophilic clays, viscosifiers, weighting agents, bridging agents, fluid loss control agents, additives to reduce or control low temperature rheology, additives to provide thinning, additives for enhancing viscosity, additives for high temperature high pressure control, emulsion stability, and inhibit corrosion.
  • Weighting agents or density materials suitable for use in wellbore fluid formulations in accordance with the present disclosure include, but are not limited to, hematite, magnetite, iron oxides, illmenite, barite, siderite, celestite, dolomite, calcite, manganese oxides, halites and the like.
  • the micronized weighting agents may be coated with a dispersant.
  • MICROBARTM is an example of commercially available weighting agent manufactured and distributed by M-I L.L.C. that may be used in the fluids disclosed herein.
  • weighting agents may have a weight average particle diameter (d50) in a range having a lower limit selected from any one of 0.5 pm, 1 pm, 2 pm, and 5 pm, to an upper limit selected from any one of 3 pm, 6 pm, 8 pm, and 10 pm, where any lower limit may be combined with any upper limit.
  • the weighting agents may have a weight average particle diameter (d50) in a range of 6 pm to 8 pm.
  • Flat rheology wellbore fluids in accordance with the present disclosure may include one or more thinners to reduce flow resistance and gel development prior to operations downstream of drilling, such as modifying fluid rheology prior to running casing.
  • wellbore fluid thinners include lignosulfonates, lignitic materials, modified lignosulfonates, polyphosphates, fatty alcohol sulfates, fatty alcohol ether sulfates, akylbenzenesulfonates, and tannins.
  • thinners include the product of a reaction between an alkyl cyclic anhydride and a polar reactant such as an alkyl amine, alkanolamine, or polyamine to form a covalent linkage such as an amide or imide.
  • alkyl cyclic anhydrides in accordance with the present disclosure may be of the general formula:
  • polar reactants used to generate thinners in accordance with the present disclosure may include Cl to C10 alkyl amines, such as methyl amine, ethyl amine, and the like.
  • Alkyl amines may be substituted or non-substituted, branched or unbranched, saturated and unsaturated.
  • alkyl amines may include aryl groups or other aromatic structures such as benzyl, phenyl, phenolic, and the like.
  • alkanolamines used to generate thinners in accordance with the present disclosure may include ethanolamine, diethylethanolamine, diethanolamine, triethanolamine, methyl ethanolamine, ethyl ethanolamine, propylethanolamine, methyl diethanolamine, ethyl diethanolamine, dimethylethanolamine, diethyl ethanolamine, and the like.
  • alkanolamines include polyetheramines, amine functionalized oligomers and polymers of ethylene oxide and propylene oxide, polyesteramines, polysilaneamines, polysiloxaneamines, polyalkylamines such as polybutadieneamine, and the like.
  • Polar reactants used to generate thinners in accordance with the present disclosure may also include polyamines such as ethylene diamine, diethylene triamine, triethylene tetramine, tetraethyl ene pentamine, 1 ,4-aminobutane, l,3-diaminobutane, hexamethylene diamine, 3 (n-isopropyl-amino)propylamine, N,N'-diethyl-l,3-propanediamine, hexapropylene heptamine, penta(l-methyl propylene) hexamine, tetrabutylenepentamine, hexa-(l,l dimethyl ethyl ene) heptamine, di(l-methylbutylene)triamine, pentaamylhexamine, and the like.
  • polyamines such as ethylene diamine, diethylene triamine, triethylene tetramine, tetraethyl ene
  • Polyamines may also be cyclic polyamines, including six-member rings such as piperidine, piperizine, or higher order rings such as seven- member, eight-member, and the like. Cyclic polyamines may also incorporate one or more heteroatoms such as oxygen or sulfur, including cyclic polyamines such as morpholine, thiomorpholine, and the like.
  • thinners may include polymeric inhibitors such as polyisobutylene succinic anhydride (PIBSA), PIBSA amine adducts such as amino alcohol derivatives PIBSA/monoethanolamine, PIBSA/diethanolamine, PIBSA/N- hydroxyethyl piperazine, PIBSA/3-hydroxybutylamine, PIBSA/N,N,N'-tris-(2- hydroxyethyl)ethylenediamine, and PIBSA/tris-(hydroxymethyl)aminomethane, polyacrylates, polyoxyalkylenes, block copolymers, and the like.
  • polymeric inhibitors such as polyisobutylene succinic anhydride (PIBSA), PIBSA amine adducts such as amino alcohol derivatives PIBSA/monoethanolamine, PIBSA/diethanolamine, PIBSA/N- hydroxyethyl piperazine, PIBSA/3-hydroxybutylamine,
  • RheThinTM is a commercially available thinning agent manufactured and distributed by M-I L.L.C. that may be used in the fluids disclosed herein [0045]
  • the fluids disclosed herein are useful in the drilling, completion and working over of subterranean oil and gas wells, including deepwater wells.
  • the fluids disclosed herein may find use in formulating drilling muds and completion fluids that allow for the easy and quick removal of the filter cake.
  • Such muds and fluids are especially useful in the drilling of horizontal wells into hydrocarbon bearing formations.
  • Conventional methods can be used to prepare the completion fluids disclosed herein in a manner analogous to those normally used, to prepare conventional oil-based fluids.
  • a desired quantity of oleaginous fluid such as a base oil and a suitable amount of a surfactant are mixed together and the remaining components are added sequentially with continuous mixing.
  • An invert emulsion may also be formed by vigorously agitating, mixing or shearing the oleaginous fluid and the non-oleaginous fluid.

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Abstract

L'invention concerne un procédé de forage d'un puits de forage pouvant comprendre le forage du puits de forage à l'aide d'un fluide de puits de forage qui a des valeurs de propriétés rhéologiques pour 6 tours/minute, 10 minutes de gel, point d'écoulement, et/ou rapport de gel de 10 minutes à 10 secondes qui représentent +/ 20 % des valeurs moyennes sur une plage de température de 40° F à 300° F ; et le conditionnement du puits de forage avec moins de 2 volumes de trous. Le fluide de puits de forage peut comprendre une phase externe oléagineuse ; une phase interne non oléagineuse ; un émulsifiant amidoamine stabilisant la phase interne non oléagineuse dans la phase externe oléagineuse ; au moins deux agents mouillants huileux ; un modificateur de rhéologie ; et un agent alourdissant ayant un d50 allant de 5 à 10 µm.
PCT/US2019/060513 2018-11-09 2019-11-08 Fluides de puits de forage à rhéologie plate pour générer des puits de forage propres Ceased WO2020097489A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
BR112021008937-3A BR112021008937A2 (pt) 2018-11-09 2019-11-08 fluidos de poço de reologia plana para gerar poços limpos
US17/291,627 US11624018B2 (en) 2018-11-09 2019-11-08 Flat rheology wellbore fluids for generating clean wellbores

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201862758224P 2018-11-09 2018-11-09
US62/758,224 2018-11-09

Publications (1)

Publication Number Publication Date
WO2020097489A1 true WO2020097489A1 (fr) 2020-05-14

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BR (1) BR112021008937A2 (fr)
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US11555138B2 (en) 2017-02-26 2023-01-17 Schlumberger Technology Corporation Fluids and methods for mitigating sag and extending emulsion stability
US11708519B2 (en) 2017-02-26 2023-07-25 Schlumberger Technology Corporation Additive to improve cold temperature properties in oil-based fluids
US12163092B2 (en) 2021-09-30 2024-12-10 Saudi Arabian Oil Company Polyhedral oligomeric silsesquioxane as rheology booster for invert emulsion oil-based mud

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